Prevention, actuation and control of deployment of memory-shape polymer foam-based expandables

ABSTRACT

Actuation and control of the deployment of a polymeric memory-shape material on a wellbore device on a downhole tool may be accomplished by treating a compacted or compressed polymeric memory-shape material with an optional deployment fluid to lower its T g  and/or decrease its rigidity, thereby softening the polymeric shape-memory material at a given temperature and triggering its expansion or recovery at a lower temperature. Recovering the polymeric shape-memory material may occur by its being exposed to a particular temperature range. Alternatively, the deployment of the compacted or compressed polymeric memory-shape material may be prevented or inhibited by shielding the material with an environment of a fluid that does not substantially lower its T g , decrease its rigidity or both, and then subsequently contacting the material with a deployment fluid. The deployment fluid may be removed during the method.

CROSS-REFERENCE TO RELATED APPLICATION

This application is a continuation-in-part application of U.S. patentapplication Ser. No. 12/763,363 filed Apr. 20, 2010, issued as U.S. Pat.No. 8,353,346 on Jan. 15, 2013, incorporated herein by reference in itsentirety.

TECHNICAL FIELD

The present invention relates to devices used in oil and gas wellboresemploying shape-memory materials that remain in an altered geometricstate during run-in; once the devices are in place downhole and areexposed to a given temperature at a given amount of time, the devicesattempt to return to their original geometric position prior toalteration. More particularly, the present invention relates to suchdevices where the T_(g) and/or its rigidity decrease by optionally usinga deployment fluid or which deployment fluid may be removed from contactwith the devices.

TECHNICAL BACKGROUND

Various methods of filtration, wellbore isolation, production control,wellbore lifecycle management, and wellbore construction are known inthe art. The use of shaped memory materials in these applications havebeen disclosed for oil and gas exploitation. Shape Memory Materials aresmart materials that have the ability to return from a deformed orcompressed state (temporary shape) to their original (permanent) shapeinduced by an external stimulus or trigger (e.g. temperature change). Inaddition to temperature change, the shape memory effect of thesematerials may also be triggered by an electric or magnetic field, light,contact with a particular fluid or a change in pH. Shape-memory polymers(SMPs) cover a wide property range from stable to biodegradable, fromsoft to hard, and from elastic to rigid, depending on the structuralunits that constitute the SMP. SMPs include thermoplastic and thermoset(covalently cross-linked) polymeric materials. SMPs are known to be ableto store multiple shapes in memory.

Dynamic Mechanical Analysis (DMA), also called dynamic mechanicalthermal analysis (DMTA) or dynamic thermomechanical analysis is atechnique used to study and characterize SMP materials. It is mostuseful for observing the viscoelastic nature of these polymers. Thesample deforms under a load. From this, the stiffness of the sample maybe determined, and the sample modulus may be calculated. By measuringthe time lag in the displacement compared to the applied force it ispossible to determine the damping properties of the material. The timelag is reported as a phase lag, which is an angle. The damping is calledtan delta, as it is reported as the tangent of the phase lag.

Viscoelastic materials such as shape-memory polymers typically exist intwo distinct states. They exhibit the properties of a glass (highmodulus) and those of a rubber (low modulus). By scanning thetemperature during a DMA experiment this change of state, the transitionfrom the glass state to the rubber state, may be characterized. Itshould be noted again that shaped memory may be altered by an externalstimulus other than temperature change.

The storage modulus E′ (elastic response) and loss modulus E″ (viscousresponse) of a polymer as a function of temperature are shown in FIG. 1.The nature of the transition state of the shaped memory polymer affectsmaterial's shape recovery behavior and can be descriptive of thepolymer's shape recovery. Referring to FIG. 1, the Glass State isdepicted as a change in storage modulus in response to change intemperature which yields a line of constant slope. The Transition Statebegins when a slope change occurs in the storage modulus as thetemperature is increased. This is referred to as the T_(g) Onset whichin FIG. 1 is approximately 90° C. The T_(g) Onset is also the pointwhere shape recovery can begin. T_(g) for a shape-memory polymerdescribed by FIG. 1 is defined as the peak of the loss modulus, which inFIG. 1 is approximately 110° C. If the slope's change of the storagemodulus were represented by a vertical line of undefined slope, thematerial shape recovery would occur at a specific temperature andtransition immediately from the glassy state to the rubber state.Generally, the more gradual the slope change of the storage modulus inthe transition state, the greater the range of temperatures whichexhibit characteristics of both the glass and rubber states. Thetransition state is the area of interest for the SMP material's shaperecovery characteristics. It should also be evident that shape recoverywould occur more slowly if stimulus temperature is closer to the T_(g)Onset temperature and that shape recovery would be more rapid as thestimulus temperature approached or exceeded the T_(g).

One method of making use of the unique behavior of shape-memory polymersis via temperature response described above. An example is seen in FIG.2. The finished molded part 100 of shape-memory polymer has a definedT_(g) and T_(g) Onset. This may be considered an original geometricposition of the shape-memory material. The part is then heated close tothe T_(g) of the polymer. Force is applied to the finished part toreshape the part into a different configuration or shape 100′. This maybe considered an altered geometric position of the shape-memorymaterial. The reshaped part 100′ is then cooled below the shape-memorypolymer's T_(g) Onset and the force removed. The finished part 100′ willnow retain the new shape until the temperature of the part is raised tothe T_(g) Onset at which point shape recovery will begin and the partwill attempt to return to its original shape 100 or if constrained, thepart will conform to the new constrained shape 100″. This shape 100″ maybe considered the shape-memory material's recovered geometric position.

U.S. Pat. No. 7,318,481 assigned to Baker Hughes Incorporated discloseda self-conforming expandable screen which comprises a thermosetting opencell shape-memory polymeric foam. The foam material composition isformulated to achieve the desired transition temperature slightly belowthe anticipated downhole temperature at the depth at which the assemblywill be used. This causes the conforming foam to expand at thetemperature found at the desired depth.

Flawless installation and deployment of memory-shape polymer foam-basedconformable sand screens, packing elements and other downhole tools aretwo crucial steps that determine the overall success of the expandabletool's operation. These steps may be challenging to execute. Therefore,effective prevention of the deployment during the installation, flawlesstriggering of the deployment of the expandable elements at theappropriate time, and reliable control of the rate and the extent of thedeployment are essential for the expandable elements' successfulperformance would be very desirable and important. It would be veryhelpful to discover a method and device for precisely installing anddeploying an element made of shaped memory material at a particularlocation downhole to achieve some desired function of filtration,wellbore isolation, production control, wellbore lifecycle management,and wellbore construction. Generally, the more control and versatilityfor deploying an element the better, as this gives more flexibility indevice designs and provides the operator more flexibility in designing,placement and configuration of the wellbore devices.

SUMMARY

There is provided, in one non-limiting form, a wellbore device thatincludes at least one polymeric shape-memory material having an originalglass transition temperature (T_(g)) and an original rigidity. Thewellbore device also includes a deployment fluid contacting thepolymeric shape-memory material in an amount effective to have an effectselected from the group consisting of lowering the T_(g) and/ordecreasing the rigidity.

There is additionally provided in another non-restrictive version awellbore device that includes a substrate e.g. a billet and at least onepolymeric shape-memory material on the substrate. The polymericshape-memory material has an original glass transition temperature(T_(g)) and an original rigidity. The polymeric shape-memory materialmay be a polyurethane, a polyurethane made by reacting a polycarbonatepolyol with a polyisocyanate, a polyamide, a polyurea, a polyvinylalcohol, a vinyl alcohol-vinyl ester copolymer, a phenolic polymer, apolybenzimidazole, polyethylene oxide/acrylic acid/methacrylic acidcopolymer crosslinked with N,N′-methylene-bis-acrylamide, polyethyleneoxide/methacrylic acid/N-vinyl-2-pyrrolidone copolymer crosslinked withethylene glycol dimethacrylate, polyethylene oxide/poly(methylmethacrylate)/N-vinyl-2-pyrrolidone copolymer crosslinked with ethyleneglycol dimethacrylate, and combinations thereof. The wellbore device mayadditionally include a deployment fluid contacting the polymericshape-memory material in an amount effective to have an effect oflowering the T_(g) to a second and lower T_(g) and/or decreasing theoriginal rigidity to a second, decreased rigidity. The deployment fluidmay be optionally removed. The wellbore device has the property thatwhen substantially all of the deployment fluid is removed from thepolymeric shape-memory material, an effect is obtained that may includerestoring the T_(g) to within at least about 90% of the original T_(g)and/or restoring the rigidity within at least about 25% of the originalrigidity.

In another non-limiting embodiment there is provided a method ofinstalling a wellbore device on a downhole tool in a wellbore. Themethod involves introducing the downhole tool bearing the wellboredevice into a wellbore. Again, the wellbore device includes at least onepolymeric shape-memory material having an original T_(g) and an originalrigidity. The polymeric shape-memory material is in an altered geometricposition and the polymeric shape-memory material is contacted by a firstfluid. The first fluid is substantially removed. The method furtherinvolves contacting the polymeric shape-memory material with adeployment fluid in an amount effective to have an effect selected fromthe group consisting of lowering the T_(g) and/or decreasing therigidity. The deployment fluid may be optionally removed. The methodadditionally involves recovering the polymeric shape-memory materialfrom its altered geometric position for run-in downhole to a recoveredgeometric position.

Alternatively there is further provided a method of installing awellbore device on a downhole tool in a wellbore, where the methodinvolves introducing the downhole tool bearing the wellbore device intoa wellbore. The wellbore device comprises at least one polymericshape-memory material having an original glass transition temperature(T_(g)) and an original rigidity, where the polymeric shape-memorymaterial is in an altered geometric position and the polymericshape-memory material is contacted by brine or oil. The methodadditionally includes recovering the polymeric shape-memory materialfrom its altered geometric position, in the absence of a deploymentfluid, upon the occurrence of an event which may include, but is notnecessarily limited to (1) the polymeric shape-memory material reachinga temperature between about 10° F. to about 150° F.; (2) the polymericshape-memory material reaching a temperature within 10° F. of its T_(g);and/or (3) the polymeric shape-memory material being temporarily exposedto a heating device that increases the temperature above the Tg longenough to deploy the polymeric shape-memory material.

The wellbore device may have a property that when the polymericshape-memory material is recovered from its altered geometric position,an effect is obtained selected from the group consisting of restoringthe T_(g) to within at least about 90% of the original T_(g), restoringthe rigidity within at least about 25% of the original rigidity, andboth.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a graph of storage modulus E′ (elastic response) (leftvertical axis) and modulus E″ (viscous response) (right vertical axis)as a function of temperature for a shape memory polymers illustratingthe change in each modulus as the polymer is heated from the Glass Statethrough the Transition State to the Rubber State;

FIG. 2 is a photograph of a finished shape-memory polymer part before itis heated close to the T_(g) of the polymer and force is applied toreshape it to a different configuration or shape and then cooled belowthe polymer's onset T_(g), and finally when the part is heated to theonset T_(g) at which point recovery will begin and the part returns toat or near its original shape;

FIG. 3 is a schematic illustration of polyurethane chains coupled viahydrogen bonding, illustrating the crystal structure of polyurethanewhere the mobility of polymer chains is limited, therefore the materialhas higher T_(g);

FIG. 4 is a schematic illustration of the hydrogen bonding networkbetween polyurethane chains being disrupted by an alcohol deploymentfluid ROH, showing that the polymer chains are decoupled and relativelymore mobile; therefore, T_(g) of the material is lower and its rigidityis reduced;

FIG. 5 is a chart of % deployment of compacted samples of theshape-memory polyurethane-polycarbonate rigid open-cell foam invegetable oil and water as a function of time at 65° C.;

FIG. 6 is a graph of the storage (E′) and loss (E″) moduli of the foamsamples immersed in vegetable oil and water as functions of thetemperature; the glass transition temperature of the polymer immersed inliquid (T_(g)) corresponds to the peak value of the loss modulus E″;

FIG. 7 is a graph of the deployment temperatures of compacted samples ofa polymeric foam shape-memory material in water as a function oftemperature;

FIG. 8 is a graph of T_(g) as a function of % ethylene glycol monobutylether (EGMBE) in an alcohol-based deployment fluid illustrating that theT_(g) of the polymeric shape-memory material decreases as the EGMBEcontent in the deployment fluid increases; and

FIG. 9 is a chart illustrating that the higher the content of the EGMBEin an alcohol-based deployment fluid is, the less time it takes todeploy the polymeric shape-memory material to gauge hole diameter.

DETAILED DESCRIPTION

It has been discovered that the actuation and control of the deploymentof the memory-shape polymer foam-based expandables can be accomplishedby treating the compacted expandables with deployment fluids reducingthe glass transition temperature of the polymer, T_(g), softening thepolymer material at a given temperature and, therefore, triggering itsexpansion. In another non-limiting embodiment, the expansion of thememory-shape polymer foam may be accomplished without a deployment fluid(that is, in the absence of such a specially engineered fluid such as asurfactant or alcohol) by subjecting the compacted expandable to acertain or particular temperature range. Alternatively, the deploymentof the compacted expandables at a given temperature may be prevented byshielding the expandables with a screen or shield of the fluids from thenaturally occurring wellbore deployment fluids.

Wellbore devices, such as those used in filtration, wellbore isolation,production control, lifecycle management, wellbore construction and thelike may be improved by including the shape-memory materials that arerun into the wellbore in altered geometric positions or shapes where theshape-memory materials change to their respective original or recoveredgeometric positions or shapes at different T_(g) Onsets and/or differentslope changes (the slope change in the respective transition state froma glass state to a rubber state).

The shape-memory material is made in one non-limiting embodiment fromone or more polyol, such as, but not limited to, a polycarbonate polyoland at least one isocyanate, including, but not necessarily limited to,a modified diphenylmethane diisocyanate (MDI), as well as otheradditives including, but not necessarily limited to, blowing agents,molecular cross linkers, chain extenders, surfactants, colorants andcatalysts.

The shape-memory polyurethane materials are capable of beinggeometrically altered, in one non-limiting embodiment compressedsubstantially, e.g., 20˜30% of their original volume, at temperaturesabove their onset glass transition temperatures (T_(g)) at which thematerial becomes soft. While still being geometrically altered, thematerial may be cooled down well below its Onset T_(g), or cooled downto room or ambient temperature, and it is able to remain in the alteredgeometric state even after the applied shape altering force is removed.When the material is heated near or above its Onset T_(g), it is capableof recovery to its original geometric state or shape, or close to itsoriginal geometric position; a state or shape which may be called arecovered geometric position. This is optionally done in the absence ofa deployment fluid. In other words, the shape-memory material possesseshibernated shape-memory that provides a shape to which the shape-memorymaterial naturally takes after its manufacturing. The compositions ofpolyurethanes and other polymeric shape-memory materials are able to beformulated to achieve desired onset glass transition temperatures whichare suitable for the downhole applications, where deployment can becontrolled for temperatures below Onset T_(g) of devices at the depth atwhich the assembly will be used.

Generally, polyurethane polymer or polyurethane foam is considered poorin thermal stability and hydrolysis resistance, especially when it ismade from polyether or polyester. It has been previously discovered thatthe thermal stability and hydrolysis resistance are significantlyimproved when the polyurethane is made from polycarbonate polyols andmethylene diphenyl diisocyanate (MDI) as noted above. The compositionsof polyurethane foam herein are able to be formulated to achievedifferent glass transition temperatures within the range from 60° C. to170° C., which is especially suitable to meet most downhole applicationtemperature requirements. More details about these particularpolyurethane foams or polyurethane elastomers may be found in U.S. Pat.No. 7,926,565, incorporated herein by reference in its entirety.

Notwithstanding the above, the wellbore devices described herein andmethods of using them may be practiced with a wide variety of polymericshape-memory materials including, but not necessarily limited to,polyurethanes, polyurethanes made by reacting a polycarbonate polyolwith a polyisocyanate, polyamides, polyureas, polyvinyl alcohols, vinylalcohol-vinyl ester copolymers, phenolic polymers, polybenzimidazole,polyethylene oxide/acrylic acid/methacrylic acid copolymer crosslinkedwith N,N′-methylene-bis-acrylamide, polyethylene oxide/methacrylicacid/N-vinyl-2-pyrrolidone copolymer crosslinked with ethylene glycoldimethacrylate, polyethylene oxide/poly(methylmethacrylate)/N-vinyl-2-pyrrolidone copolymer crosslinked with ethyleneglycol dimethacrylate, and combinations thereof. While it is expectedthat in most implementations the polymeric shape-memory material will bea cellular foam, it is also to be understood that other physicalstructures which are not cellular foams, for instance an elastomer, mayfind use as the polymeric shape-memory material. Of course, elastomersmay also be cellular in some non-limiting embodiments.

The methods described herein may be performed without the use of or inthe absence of a deployment fluid. The polymeric shape-memory materialmay be recovered from its altered geometric position (in onenon-limiting embodiment a compressed position) at a certain temperaturerange or temperature window, for instance subjecting or exposing thepolymeric shape-memory material in its altered geometric position to atemperature within a range of about 10° F. (about −12° C.) independentlyto about 150° F. (about 66° C.); alternatively a range from about 15° F.(about −9° C.) independently to about 140° F. (60° C.), in anothernon-restrictive version from about 20° F. (−7° C.) independently toabout 130° F. (54° C.). The term “independently” as used herein withrespect to a range means that any lower threshold may be used togetherwith any upper threshold to create a suitable alternative range for thatparameter.

In an alternate embodiment, recovering the polymeric shape-memorymaterial from its altered geometric position (deployment) may occur whenthe polymeric shape-memory material reaches a temperature within 10° F.of its T_(g), alternatively within 7° F. of its T_(g), or in anothernon-limiting embodiment within 5° F. of its T_(g).

In a different non-restrictive version, recovering the polymericshape-memory material from its altered geometric position (deployment)may occur when the polymeric shape-memory material is exposed to aheating device that temporarily increases the temperature above thematerial Tg. Suitable heating devices include, but are not necessarilylimited to, catalytic chambers, such as those described in U.S. Pat. No.7,708,073, assigned to Baker Hughes Incorporated, incorporated herein byreference in its entirety; electrothermic heaters using wireline orelectric submersible pump (ESP) cables, such as those utilized by TycoThermal Controls Co.; and the like. Other suitable heating devicesinclude, but are not necessarily limited to those involving microwaveheating of the shape-memory material and/or the brine with which it iscontacted, such as described in U.S. Patent Application Publication No.2012/0012319 A1 (also incorporated herein by reference in its entirety)and the like; as well as any devices involving exothermic reactions(other than combustion) such as galvanic corrosion of Mg powder when amixture of Mg/Fe powders is added to the brine, and the like; heating ofconductive pipe on which the screen is mounted using inductive heater;and heating using strontium sources as described in U.S. Pat. No.8,127,840, additionally incorporated by reference herein in itsentirely, and the like.

Suitable optional deployment fluids include, but are not necessarilylimited to water, brines, dimethyl sulfoxide, ketones, alcohols,glycols, ethers, hydrocarbons, and mixtures thereof. Specific examplesof suitable polar fluids include, but are not necessarily limited to,water, brines, methanol, ethanol, isopropyl alcohol, ethylene glycolmonobutyl ether (EGMBE), dimethyl sulfoxide, and acetone. Specificexamples of suitable non-polar fluids include, but are not necessarilylimited to, vegetable oils, mineral oil, LVT 200 oil, and crude oil. LVT200 oil is described as hydrotreated distillate of light C9-16containing cycloparaffinic, isoparaffinic, and normal paraffinichydrocarbons available from Delta Drilling Products & Services, LLC.Generally, the more polar a fluid is, the more likely the fluid willserve as a deployment fluid, although nearly all fluids may exhibit somebenefit as a deployment fluid, depending on the polymeric shape-memorymaterial being treated. It should be understood that the particulardeployment fluid should not be a solvent for the polymeric shape-memorymaterial. That is, that the polymeric shape-memory material should notbe soluble in the deployment fluid to any appreciable extent.

The amount of the optional deployment fluid effective to affect theT_(g) and/or the rigidity is a quantity sufficient to essentiallysaturate or soak all of the polymeric shape-memory material that isdesired to be affected. Since it is expected that in most embodimentsthe polymeric shape-memory material will be an open cell foam, it maynot be physically possible for the deployment fluid to infiltrate all ofthe cells, but at least 25 vol %, alternatively at least 50 vol %, andeven at least 90 vol % of the material may be contacted. In the eventthat the polymeric shape-memory material is not a foam, or is instead amaterial such as an elastomer which is non-cellular, it may be moredifficult for the deployment fluid to reach all of the polymer chains inthe material. In non-limiting embodiments, more time may be needed forthe deployment fluid to be more effective or the deployment fluid mayneed to be altered, for instance a fluid having relatively smallermolecules to permit the polymer chain structure to be infiltrated.

One non-limiting theory about how the method and devices describedherein may operate may be seen with reference to FIGS. 3 and 4. As shownin FIG. 3, polyurethane chains coupled via hydrogen bonding representthe crystal structure of polyurethane and because the polyurethanechains are more ordered and regular, the polymer chains are relativelyparallel, the crystalline polyurethane is more rigid. The mobility ofpolymer chains is limited, therefore the material has higher T_(g).However, if another substance is introduced, for instance an alcohol,ROH, serving as a deployment fluid, the hydrogen bonding network betweenpolyurethane chains is disrupted. The polymer chains are decoupled fromone another and relatively more mobile, therefore, the T_(g) of thematerial is lower and the rigidity of the material is reduced, forinstance to a second, lower T_(g) and a second, decreased rigidity,respectively.

It has been discovered that water alone cannot decrease the T_(g) of thepolycarbonate-polyurethane material significantly enough to deploy awellbore device at 115° F. (46.1° C.), for example. On the other hand,it has been found that a EGMBE/MeOH/KCl brine deployment fluid candeploy a wellbore device at this temperature. A non-limiting explanationis that a single water molecule has a negatively charged oxygen and twopositively charged hydrogen atoms. Therefore it can make two H-bondssimultaneously: in a first scenario of one with the oxygen atom ofcarboxyl group of one polymer chain, the other with an oxygen atom of acarboxyl group of a second polymer chain. However, it may also have asecond scenario of a hydrogen bond to one carboxyl oxygen on a firstpolymer chain and a second hydrogen bond to a hydrogen atom on aurethane link of a second polymer chain. Thus chains 1 and chain 2 arenot very effectively decoupled since they are coupled via a single watermolecule. Note however that water molecules can also form H-bondedchains between themselves. Therefore, there may be coupling such as:Chain 1-water- . . . -water-Chain 2. This coupling via chains of watermolecules would not be expected to be strong.

Alternatively, ROH alcohols cannot form H-bonds with two chainssimultaneously via the first scenario described above, but may do so viathe second scenario. In another non-limiting embodiment, such couplingmay occur through a glycol or through a bridge such as: Chain 1-ROH— . .. —ROH-Chain 2, but would not be expected to be a strong coupling.However, the alkyl portions of alcohol molecules may serve as thespacers between the polymer chains and decouple the chains moreeffectively than water alone. Therefore, the polymer's T_(g) in alcoholsor more complex (multi-component) deployment fluids may be lower thanthat achieved in only water.

In a polyurethane-polycarbonate polymer, in one non-restrictive versionherein, there are many carboxyl oxygen atoms on the chain and fewerhydrogen atoms of the urethane linkages. Thus, water molecules may makemany Chain 1-water-Chain 2 bridges, while alcohols ROH may make fewerChain 1-ROH-Chain 2 bridges since there are relatively fewer hydrogenatoms of polyurethane linkages on the chain compared to carboxyl oxygenatoms.

Deployment fluids which cannot disrupt the hydrogen bonding of thepolymer chains by engaging in hydrogen bonding themselves may stillaffect the T_(g) and rigidity of the polymer chains by simply physicallyinterfering or coming between the hydrogen bonding sites of the adjacentpolymer chains to prevent or inhibit the chains from hydrogen bondingwith each other. This non-limiting understanding may help explain whynon-polar materials such as hydrocarbons, e.g. oils, can still lowerT_(g) and reduce rigidity of the polymer materials. It may thus beunderstood that there is roughly a spectrum of useful deployment fluids,where the more polar fluids have more of an effect and the less polarfluids have less of an effect.

It should also be realized that the effect of the deployment fluid isreversible. That is, when the deployment fluid is removed, the T_(g) ofthe polymeric shape-memory material as well as the original rigidity arerestored. As a practical matter, it is not possible to remove all of thedeployment fluid from the polymeric shape-memory material once it hasbeen contact thereby or even saturated therewith. Since the polymericshape-memory material is porous, and in one beneficial embodiment is anopen cell foam, it is simply physically difficult to remove all of thedeployment fluid once it is contacted with and introduced into the foam.Thus, in one non-limiting embodiment “substantially removing all of thedeployment fluid” is defined herein as removing at least 90 volume % ofthe fluid, alternatively at least about 95 vol %, and in another versionat least 99 vol %. Of course, complete removal is a goal. In one methoddescribed herein, substantially all of the deployment fluid is removed.

Thus, it may be understood that with substantially all of the deploymentfluid is removed from the polymeric shape-memory material, the effectsmay be restoring the T_(g) to within at least 90% of the original T_(g)and/or restoring the rigidity within at least 25% of the originalrigidity. Alternatively, the T_(g) is restored to within at least 95% ofthe original T_(g) and/or the rigidity is restored to within at least50% of the original rigidity. In another non-restrictive version, theT_(g) is restored to within at least 99% of the original T_(g) and/orthe rigidity is restored to within at least 90% of the originalrigidity. Of course, complete restoration of these properties isdesirable. Rigidity may be restored when, in a non-limiting example, thealcohol ROH is removed from the schematic structure shown in FIG. 4 andthe hydrogen bonding between the polymer chains is restored, asschematically shown in FIG. 3.

In one non-limiting embodiment, an optional surfactant may be used tohelp recover a deployment fluid from the polymeric shape-memorymaterial. Suitable surfactants when the deployment fluid being removedinclude a polar fluid such as water, brines, dimethyl sulfoxide,ketones, alcohols, glycols and ethers may include, but not necessarilylimited to, anionic, cationic, amphoteric, and non-ionic surfactants.Suitable surfactants when the deployment fluid being removed is anon-polar fluid such as an oil, e.g. a plant oil, for instance, oliveoil or sunflower oil, may include, but not necessarily limited to,anionic, cationic, amphoteric, and non-ionic surfactants

The method described herein may have considerable benefit. In onenon-limiting example, a single wellbore device product having only onetype of polymeric shape-memory material may be used in a variety ofapplications requiring deployment of the polymeric shape-memory materialfrom its altered geometric position to a recovered geometric position atdifferent T_(g)s simply by contacting, soaking or saturating thepolymeric shape-memory material in its altered geometric position in asuitable different deployment fluid designed to alter its T_(g) indifferent amounts. Alternatively, the deployment fluid may besubsequently completely removed, or in another non-restrictive version,the method may be practiced in the absence of a deployment fluid whereon a certain temperature window or range deploys the polymericshape-memory material from its altered or compressed geometric state orposition.

In one specific non-limiting embodiment, the shape-memory material is apolyurethane material that is extremely tough and strong and that iscapable of being geometrically altered and returned to substantially itsoriginal geometric shape. The T_(g) of the shape-memory polyurethanefoam may range from about 40° C. to about 200° C. and it isgeometrically altered by mechanical force at 40° C. to 190° C. Whilestill in geometrically altered state, the material may be cooled down toroom temperature or some other temperature below the T_(g) of eachshape-memory material. The shape-memory polyurethane is able to remainin the altered geometric state even after applied mechanical force isremoved. However, as described herein, the polymeric shape-memorymaterial in its altered geometric state may be contacted, saturated orsoaked in a deployment fluid which alters its T_(g), generally loweringit. When the compressed polymeric shape-memory material is heated toabove its reduced or modified onset T_(g), it is able to return to itsoriginal shape, or close to its original shape. The time required forgeometric shape recovery can vary from about 20 minutes to 40 hours orlonger depending on the slope of the transition curves as the materialmoves from a glass state to a rubber state. If the material remainsbelow the altered or lowered onset T_(g) it remains in the geometricallyaltered state and does not change its shape.

In one non-limiting embodiment, when shape-memory polyurethane is usedas a downhole device, the device remains in an altered geometric stateduring run-in until it reaches to the desired downhole location.Usually, downhole tools traveling from surface to the desired downholelocation take hours or days. Thus, it may be helpful to match thealtered onset T_(g)s of the material with the expected downholetemperatures. The deployment fluids described herein help the designerprevent premature deployment of the polymeric shape-memory material andcontrol when and where deployment occurs, thus permitting flawlessimplementation and deployment of the wellbore device.

In some non-limiting embodiments, when the temperature is high enoughduring run-in, the devices made from the shape-memory polyurethane couldstart to recover. To avoid undesired early recovery during run-in,delaying methods may or must be taking into consideration. In previousnon-limiting embodiments, a poly(vinyl alcohol) (PVA) film or othersuitable film may be used to wrap or cover the outside surface ofdevices made from shape-memory polyurethane to prevent recovery duringrun-in. Once devices are in place downhole for a given amount of time attemperature, the PVA film is capable of being dissolved in the water,emulsions or other downhole fluids and, after such exposure, theshape-memory devices may recover to their original geometric shape orconform to the bore hole or other space. However, the apparatus andmethods described herein instead prevent undesired early recovery of thepolymeric shape-memory material by contacting, soaking or enveloping thematerial in a deployment fluid that alters the T_(g) sufficiently tohelp inhibit or prevent premature deployment.

In one non-limiting embodiment, a downhole tool may have a wellboredevice that is a polymeric shape-memory material as described hereinwhich may be designed to permit fluids, but not fines or other solids topass through, such as a screen. In a different non-restrictive version,the polymeric shape-memory material may be designed to prevent fluids aswell as solids from passing therethrough, in which case the tool is apacker or other isolation device. In these and other such embodiments,the recovered geometric position of the polymeric shape-memory materialmay be to totally conform to the available space between the wellboredevice and the borehole wall or casing. When it is described herein thata device “totally conforms” to the borehole, what is meant is that theshape-memory material recovers or deploys to fill the available space upto the borehole wall. The borehole wall will limit the final, recoveredshape of the shape-memory material and in fact not permit it to expandto its original, geometric shape. In this way however, the recovered ordeployed shape-memory material, will perform the desired function withinthe wellbore. In summary, suitable wellbore devices used on theapparatus or in the methods described herein include, but are notnecessarily limited to an expansion took a screen, a packer, and anisolation plug.

The invention will now be described with respect to certain specificexamples which are not intended to limit the invention in any way butsimply to more fully illuminate it.

Example 1

The effect of polar and non-polar deployment fluids on the deployment ofthe memory-shape polymer foam-based expandables is shown in FIG. 5. Twocylindrical samples of polyurethane-polycarbonate rigid open-cell foam(h=4 mm, d=7 mm) were immersed into vegetable oil and water at 65° C.and compacted to 35.2% and 39.4% of their original height, respectively.After the compressive loads on samples were removed, the sample immersedin the vegetable oil expanded to 39.9% of its original height within 21seconds and then further expanded to only 40.9% of its original heightduring the next 2468 minutes, while the sample immersed in water rapidlyexpanded to 50.8% of its original height within 62 seconds and thengradually expanded further to 67.2% of its original height during thenext 2500 minutes. Note that the initial rapid expansion of the foamsamples reflects an elastic response of the foam to the compressive loadremoval and can be avoided if the pre-compacted samples are immersedinto the liquid to deploy. Therefore, the foam sample immersed in thevegetable oil was effectively “frozen” at 65° C., while the sampleimmersed in the water was able to continually expand with a decreasingrate as a function of time at the same temperature. Thus, thisexperiment shows that a compacted polyurethane/polycarbonate foam-basedexpandable element can be safely transported downhole and installed atthe temperatures less than at least 65° C. if the wellbore is circulatedwith an oil-based liquid. Replacement of the oil-based circulating fluidwith a water-based liquid would trigger the deployment of theexpandables at the same temperature. This experiment also shows that theonset temperature for the deployment of a foam-based element immersed inthe water is lower than 65° C.

Example 2

In this particular case of a polycarbonate-polyurethane memory-shapefoam material, it is believed that the relatively light and mobile watermolecules form hydrogen bonds with the negatively charged oxygen atomsof polycarbonate chains and the positively charged hydrogen atoms ofurethane (carbamate) links inducing their motion and likely acting as an“internal lubricant” between the polymer chains, as previouslydiscussed. A comprehensive molecular-level understanding of interactionsof water molecules with polymer chains may be provided by the MolecularDynamics simulations, described by Tamar Schlick in “Molecular Modelingand Simulation”, Springer-Verlag, New York, 2002, incorporated herein byreference.

This phenomenon effectively reduces a glass transition temperature,T_(g), of the polyurethane/polycarbonate foam immersed in the water incomparison with T_(g) of the same material immersed in vegetable oil bya ΔT_(g) of about −17° C., as seen in FIG. 6. FIG. 6 is a graph of thestorage (E′) and loss (E″) moduli of the polymeric shape-memory materialsamples immersed in oil and water as functions of the temperature. Theglass transition temperature of the polymer immersed in liquid (T_(g))corresponds to the peak value of the loss modulus E″ and indicates thatthe T_(g) is about 17° C. lower when water is used as compared to whenoil is used. Please also note the shift to the left of the storagemodulus E′ curve when water is used compared to when the oil isemployed.

Hence, the water acts as a deploying or activating agent on the polymerfoam while the vegetable oil does not display as significant T_(g)reduction and “lubricating” (rigidity reduction) properties. Therefore,by replacing a non-polar (hydrocarbon) wellbore circulating fluid whichdoes not have relatively large T_(g)-reducing properties with arelatively more T_(g)-reducing ability fluid contacting the polymer foammaterial, the onset temperature for the deployment of the memory-shapepolymer foam-based expandables may be reduced. In one non-limitingimplementation, the deployment onset temperature may be kept high duringthe transportation downhole and the installation procedures. Then theT_(g) may be lowered by replacing the oil-based circulating fluids withthe water-based ones to actuate the deployment of the expandables. Itshould be noted that the variety of possible deployment fluids is wide,and the water and the vegetable oil are used only as examples.

Example 3

As shown in FIG. 7, by changing the temperature of the circulatingliquid, it is possible to control both the rate and the extent of thedeployment of the memory-shape polymer foam-based expandables. As shownin FIG. 7, increasing the temperature increases the rate as well as theextent of the expandables' deployment. It should be noted that thiseffect holds for the foam immersed in both the more polar deploymentfluids and the non-polar deployment fluids.

Example 4

The following data support the understanding that a polar deploymentfluid which decreases T_(g) of the material relatively more than anon-polar fluid is also more effective for reducing the deployment timeof the totally conformable sand screen (TCS). In this Example the TCSwas a polyurethane/-polycarbonate foam.

The TCS material before contact with the activation fluid has a T_(g) in3% KCl solution of 71° C. After its immersion in activation fluids at115° F. for 72 hours, the T_(g)s in 3% KCl solution are as shown inTable I.

TABLE I T_(g) of the Material in 3% KCl Solution after Deployment UsingVarious Blends of EGMBE and MeOH Deployment Fluid Composition T_(g), °C. None (Tg of Material before Compaction and Deployment) 71 4% volumeEthylene Glycol Monobutyl Ether (EGMBE) 25% 44.1 volume CH₃OH and 8.9ppg KCl 5% volume EGMBE 25% volume CH₃OH and 8.9 ppg KCl 38.9 6% volumeEGMBE 25% volume CH₃OH and 8.9 ppg KCl 32.6

The results of Table I are plotted in FIG. 8. It may be seen that theT_(g) of the material decreases as the EGMBE content in the activationfluid increases.

FIG. 9 shows that the higher the content of EGMBE in the deploymentfluid, the less time it takes to deploy the TCS to gauge hole diameter.In the deployment experiments, the deployment fluids and correspondingdeployment times were as shown in Table II. It thus may be seen that thedeployment fluid which reduces T_(g) more also reduces the deploymenttime more.

TABLE II Deployment Times for Various Deployment Fluid CompositionsFluid Composition Deployment Time, hr   3% EGMBE 25% CH₃OH and 8.9 ppgKCl 22   4% EGMBE 25% CH₃OH and 8.9 ppg KCl 22 (1^(st) test) 27 (2^(nd)test)   5% EGMBE 25% CH₃OH and 8.9 ppg KCl 17 7.5% EGMBE 25% CH₃OH and8.9 ppg KCl  7 (1^(st) test)  8 (2^(nd) test) 14 (3^(rd) test)

It is to be understood that the invention is not limited to the exactdetails of construction, operation, exact materials, or embodimentsshown and described, as modifications and equivalents will be apparentto one skilled in the art. Accordingly, the invention is therefore to belimited only by the scope of the appended claims. Further, thespecification is to be regarded in an illustrative rather than arestrictive sense. For example, specific combinations of components tomake the polymeric shape-memory materials, particular T_(g)s, particulardeployment fluids used, particular temperature ranges, particularheating devices, specific downhole tool configurations, designs andother compositions, components and structures falling within the claimedparameters, but not specifically identified or tried in a particularmethod or apparatus, are anticipated to be within the scope of thisinvention.

The terms “comprises” and “comprising” in the claims should beinterpreted to mean including, but not limited to, the recited elements.For instance, a wellbore device within the descriptions herein mayconsist of or consist essentially of at least one polymeric shape-memorymaterial and a deployment fluid as defined by the claims. Similarly, amethod of installing a wellbore device on a downhole tool in a wellboremay consist of or consist essentially of introducing the downhole toolbearing the wellbore device into a wellbore where the polymericshape-memory material is contacted by a first fluid, substantiallyremoving the first fluid, contacting the polymeric shape-memory materialwith a deployment fluid and recovering the polymeric shape-memorymaterial from its altered geometric position for run-in to a recoveredgeometric position as further specified in the claims. This method mayalso consist of or consist essentially of removing the deployment fluid.

The method herein installing a wellbore device on a downhole tool in awellbore may consist essentially of or consist of introducing thedownhole tool bearing the wellbore device into a wellbore, where thewellbore device comprises at least one polymeric shape-memory materialhaving an original glass transition temperature (T_(g)) and an originalrigidity, where the polymeric shape-memory material is in an alteredgeometric position and the polymeric shape-memory material is contactedby a brine or oil; and recovering the polymeric shape-memory materialfrom its altered geometric position, in the absence of a deploymentfluid, upon the occurrence of an event including, but not necessarilylimited to (1) the polymeric shape-memory material reaching atemperature between about 10° F. to about 150° F.; (2) the polymericshape-memory material reaching a temperature within 10° F. of its T_(g);and/or (3) the polymeric shape-memory material being exposed to aheating device that increases the temperature above the material Tg.Optionally the wellbore device has the property that when the polymericshape-memory material is recovered from its altered geometric position,an effect is obtained selected from the group consisting of restoringthe T_(g) to within at least about 90% of the original T_(g), restoringthe rigidity within at least about 25% of the original rigidity, andboth.

The present invention may suitably comprise, consist or consistessentially of the elements disclosed and may be practiced in theabsence of an element not disclosed.

What is claimed is:
 1. A method of installing a wellbore device on adownhole tool in a wellbore, the method comprising: introducing thedownhole tool bearing the wellbore device into a wellbore, where thewellbore device comprises at least one polymeric shape-memory materialhaving an original glass transition temperature (T_(g)) and an originalrigidity, where the polymeric shape-memory material is in an alteredgeometric position and the polymeric shape-memory material is contactedby a first fluid; substantially removing the first fluid; contacting thepolymeric shape-memory material with a deployment fluid in an amounteffective to have an effect upon the polymeric shape-memory material,the effect selected from the group consisting of lowering the T_(g),decreasing the rigidity, and both; removing the deployment fluid; andrecovering the polymeric shape-memory material from its alteredgeometric position for run-in to a recovered geometric position; wherethe wellbore device has the property that when substantially all of thedeployment fluid is removed from the polymeric shape-memory material, aneffect is obtained selected from the group consisting of restoring theT_(g) to within at least about 90% of the original T_(g), restoring therigidity within at least about 25% of the original rigidity, and both.2. The method of claim 1 further comprising expanding the polymericshape-memory material from its altered geometric position to a recoveredgeometric position.
 3. The method of claim 1 where the polymericshape-memory material is selected from the group consisting ofpolyurethanes, polyurethanes made by reacting a polycarbonate polyolwith a polyisocyanate, polyamides, polyureas, polyvinyl alcohols, vinylalcohol-vinyl ester copolymers, phenolic polymers, polybenzimidazoles,polyethylene oxide/acrylic acid/methacrylic acid copolymer crosslinkedwith N,N′-methylene-bis-acrylamide, polyethylene oxide/methacrylicacid/N-vinyl-2-pyrrolidone copolymer crosslinked with ethylene glycoldimethacrylate, polyethylene oxide/poly(methylmethacrylate)/N-vinyl-2-pyrrolidone copolymer crosslinked with ethyleneglycol dimethacrylate, and combinations thereof.
 4. The method of claim1 where the polymeric shape-memory material is a polyurethane formed bya process comprising reacting a polycarbonate polyol with an isocyanate.5. The method of claim 1 where the first fluid is a hydrocarbon-basedfluid and where the deployment fluid is selected from the groupconsisting of water, brines, dimethyl sulfoxide, ketones, alcohols,glycols, ethers, and mixtures thereof.
 6. The method of claim 1 wherethe wellbore device is selected from the group consisting of anexpansion tool, a screen, a packer, an isolation plug and combinationsthereof.
 7. A method of installing a wellbore device on a downhole toolin a wellbore, the method comprising: introducing the downhole toolbearing the wellbore device into a wellbore, where the wellbore devicecomprises: a substrate; and at least one polymeric shape-memory materialon the substrate, the polymeric shape-memory material having an originalglass transition temperature (T_(g)) and an original rigidity, where thepolymeric shape-memory material is in an altered geometric position andthe polymeric shape-memory material is contacted by a first fluid, wherethe polymeric shape-memory material is selected from the groupconsisting of polyurethanes, polyurethanes made by reacting apolycarbonate polyol with a polyisocyanate, polyamides, polyureas,polyvinyl alcohols, vinyl alcohol-vinyl ester copolymers, phenolicpolymers, polybenzimidazoles, polyethylene oxide/acrylicacid/methacrylic acid copolymer crosslinked withN,N′-methylene-bis-acrylamide, polyethylene oxide/methacrylicacid/N-vinyl-2-pyrrolidone copolymer crosslinked with ethylene glycoldimethacrylate, polyethylene oxide/poly(methylmethacrylate)/N-vinyl-2-pyrrolidone copolymer crosslinked with ethyleneglycol dimethacrylate, and combinations thereof; substantially removingthe first fluid; contacting the polymeric shape-memory material with adeployment fluid in an amount effective to have an effect upon thepolymeric shape-memory material, the effect selected from the groupconsisting of lowering the T_(g) resulting in a second and lower T_(g),decreasing the original rigidity resulting in a second, decreasedrigidity, and both; removing the deployment fluid; and recovering thepolymeric shape-memory material from its altered geometric position forrun-in to a recovered geometric position, where the wellbore device hasthe property that when substantially all of the deployment fluid isremoved from the polymeric shape-memory material, an effect is obtainedselected from the group consisting of restoring the T_(g) to within atleast about 90% of the original T_(g), restoring the rigidity within atleast about 25% of the original rigidity, and both.
 8. The method ofclaim 7 where the polymeric shape-memory material is a polyurethaneformed by a process comprising reacting a polycarbonate polyol with anisocyanate.
 9. The method of claim 7 where the first fluid is ahydrocarbon-based fluid and where the deployment fluid is selected fromthe group consisting of water, brines, dimethyl sulfoxide, ketones,alcohols, glycols, ethers, and mixtures thereof.
 10. The method of claim7 where the wellbore device is selected from the group consisting of anexpansion tool, a screen, a packer, an isolation plug and combinationsthereof.